Pulsed hydraulic fracturing with geopolymer precursor fluids

ABSTRACT

Fracturing a reservoir includes providing a pad fluid to the reservoir via a wellbore in a well to create fractures in the reservoir, providing a fracturing fluid to the fractures via the wellbore, providing a geopolymer precursor fluid to the fractures via the wellbore, shutting in the wellbore at a wellbore pressure, thereby allowing the geopolymer precursor fluid to harden and form geopolymer proppant pillars in the fractures. Providing the geopolymer precursor fluid to the fractures includes pulsing quantities of the geopolymer precursor fluid into a continuous flow of the fracturing fluid or alternately pulsing quantities of the geopolymer precursor fluid and the fracturing fluid. An elapsed time between pulsing the quantities of the geopolymer precursor fluid is between 2 seconds and 20 minutes.

CROSS-REFERENCE TO RELATED APPLICATION

This application claims the benefit of U.S. application Ser. No. 15/711,889 filed on Sep. 21, 2017, the entire contents of which are incorporated by reference in its entirety.

TECHNICAL FIELD

This invention relates to pulsed hydraulic fracturing of a reservoir with geopolymer precursor fluids to yield isolated geopolymer proppant pillars in the reservoir.

BACKGROUND

The success of a fracturing stimulation treatment depends at least in part on the strength and distribution of the proppant used to prevent the created fracture from closing after treatment. Even for simple and wide features with high proppant placement efficiency throughout the entire fracture geometry, current mathematical and engineering concepts still overestimate the flow capacity of fractures by orders of magnitude. Permeability of the proppant pack may be reduced by a combination of factors such as residual damage from poor gel recovery, fines migration, multiphase flow, fluid momentum losses, drag forces, capillary forces, and proppant crushing and embedment. In some cases, conventional proppant packs lose up to 99% of initial conductivity due to gel damage, fines migration, multiphase flow, and non-Darcy flow.

SUMMARY

In a first general aspect, fracturing a reservoir includes providing a pad fluid to the reservoir via a wellbore in a well to create fractures in the reservoir, providing a fracturing fluid to the fractures via the wellbore, providing a geopolymer precursor fluid to the fractures via the wellbore, and shutting in the wellbore at a wellbore pressure, thereby allowing the geopolymer precursor fluid to harden and form geopolymer proppant pillars in the fractures. Providing the geopolymer precursor fluid to the fractures includes pulsing quantities of the geopolymer precursor fluid into a continuous flow of the fracturing fluid or alternately pulsing quantities of the geopolymer precursor fluid and the fracturing fluid. An elapsed time between pulsing the quantities of the geopolymer precursor fluid is between 2 seconds and 20 minutes.

Implementations of the first general aspect may include one or more of the following features.

The pad fluid may include slickwater, a linear gel, a crosslinked gel, or a viscoelastic surfactant fluid. The fracturing fluid may include slickwater, a linear gel, a crosslinked gel, or a viscoelastic surfactant fluid. In some cases, the fracturing fluid includes a proppant loading of up to 12 pounds per gallon added.

The geopolymer precursor fluid typically includes aluminosilicate, an alkaline reagent, and a permeability enhancing agent. The aluminosilicate may include at least one of calcined clay, kaolinitic clay, lateritic clay, volcanic rock, mine tailings, blast furnace slag, and coal fly ash. The alkaline reagent may include at least one of sodium silicate and potassium silicate. The permeability enhancing agent may include polylactic acid, such as polylactic acid in the form of beads, fibers, or fabric. The permeability enhancing agent may include at least one of a resin, a salt, benzoic acid, and wax beads. The salt may include an acid salt. The geopolymer precursor may also include an accelerating agent or a retarding agent. In some cases, the geopolymer precursor fluid is a first geopolymer precursor fluid, the fracturing fluid is a second geopolymer precursor fluid, and the first geopolymer precursor fluid and the second geopolymer precursor fluid differ in composition.

In some embodiments, the elapsed time between pulsing the quantities of the geopolymer precursor is between 10 seconds and 1 minute. In some embodiments, pulsing the quantities of the geopolymer precursor fluid includes pulsing discrete quantities of the geopolymer precursor fluid into the continuous flow of the fracturing fluid or alternately pulsing discrete quantities of the geopolymer precursor fluid and discrete quantities of the fracturing fluid. The discrete quantities of the geopolymer precursor fluid are typically spaced apart from each other. Pulsing the quantities of the geopolymer precursor fluid may include injecting the geopolymer precursor fluid at a rate between 1 barrel per minute and 120 barrels per minute, or injecting the geopolymer precursor fluid at a rate between 5 barrels per minute and 50 barrels per minute.

Implementations of the first general aspect may include, after providing the fracturing fluid and the geopolymer precursor fluid to the fractures, providing a continuous flow of an additional fluid to the fractures. In some cases, the geopolymer precursor fluid is a first geopolymer precursor fluid, and the additional fluid is a second geopolymer precursor fluid. In certain cases, the fracturing fluid is a first fracturing fluid, and the additional fluid is a second fracturing fluid. The second fracturing fluid may include a proppant loading of up to 12 pounds per gallon added.

In some embodiments, a compressive strength of the geopolymer proppant pillars exceeds an overburden pressure of the reservoir. The compressive strength of the geopolymer proppant pillars may be in a range of 500 pounds per square inch to 20,000 pounds per square inch. A permeability of the geopolymer proppant pillars may be in a range of 0.00001 Darcy to 20,000 Darcy.

Pulsed hydraulic fracturing with geopolymer precursor fluids yields increased productivity. Moreover, because the geopolymer precursor fluid hardens in the reservoir to form proppant pillars, the need for proppant is reduced or eliminated. Methods and systems described herein advantageously reduce proppant costs, pumping horsepower, and gel damage, when compared to conventional treatments. Methods and systems described herein also reduce the opportunity for proppant to screen out during pumping procedures.

BRIEF DESCRIPTION OF THE DRAWINGS

FIG. 1 depicts an exemplary hydraulic fracture treatment for a well.

FIG. 2 is a flowchart for a method of pulsed hydraulic fracturing with a geopolymer precursor fluid.

FIG. 3A depicts elapsed time between pulsed quantities of geopolymer precursor fluid in a continuous flow of fracturing fluid. FIGS. 3B-3D depict elapsed time between pulsed quantities of geopolymer precursor fluid and fracturing fluid.

FIG. 4 depicts a cross-sectional view of geopolymer proppant pillars in a fracture.

DETAILED DESCRIPTION

To avoid loss of conductivity of a proppant pack in a reservoir, isolated proppant pillars are formed to support the fracture and keep it open. The isolated proppant pillars form conductive channels that provide a path having high conductivity for hydrocarbon flow. As described herein, stable proppant pillars are generated by providing pulses of a geopolymer precursor fluid within a compatible fracturing fluid or by alternating pulses of a geopolymer precursor fluid with pulses of a compatible fracturing fluid through the wellbore into the reservoir at fracture pressure. The geopolymer precursor fluid includes an aluminosilicate, an alkaline reagent, and a permeability enhancing agent. The pulsing injection pattern allows the geopolymer precursor fluid to fill the fractures in an isolated pattern shape, creating proppant pillars in the fractures. The geopolymer precursor fluid hardens in the reservoir to form geopolymer proppant pillars in the fractures.

FIG. 1 depicts an example of a fracture treatment 10 for a well 12. The well 12 can be a reservoir or formation 14, for example, an unconventional reservoir in which recovery operations in addition to conventional recovery operations are practiced to recover trapped hydrocarbons. Examples of unconventional reservoirs include tight-gas sands, gas and oil shales, coalbed methane, heavy oil and tar sands, and gas-hydrate deposits. In some implementations, the formation 14 includes an underground formation of naturally fractured rock containing hydrocarbons (for example, oil, gas, or both). For example, the formation 14 can include a fractured shale. In some implementations, the well 12 can intersect other suitable types of formations 14, including reservoirs that are not naturally fractured in any significant amount.

The well 12 can include a wellbore 20, casing 22 and well head 24. The wellbore 20 can be a vertical or deviated bore. The casing 22 can be cemented or otherwise suitably secured in the wellbore 12. Perforations 26 can be formed in the casing 22 at the level of the formation 14 to allow oil, gas, and by-products to flow into the well 12 and be produced to the surface 25. Perforations 26 can be formed using shape charges, a perforating gun or otherwise.

For the fracture treatment 10, a work string 30 can be disposed in the wellbore 20. The work string 30 can be coiled tubing, sectioned pipe or other suitable tubing. A fracturing tool 32 can be coupled to an end of the work string 30. Packers 36 can seal an annulus 38 of the wellbore 20 above and below the formation 14. Packers 36 can be mechanical, fluid inflatable or other suitable packers.

One or more pump trucks 40 can be coupled to the work string 30 at the surface 25. The pump trucks 40 pump fluid 58 down the work string 30 to perform the fracture treatment 10 and generate the fracture 60. The fluid 58 can include a pad fluid, fracturing fluid, a geopolymer precursor fluid, other appropriate fluids, or any combination thereof. The pump trucks 40 can include mobile vehicles, equipment such as skids or other suitable structures.

One or more instrument trucks 44 can also be provided at the surface 25. The instrument truck 44 can include a fracture control system 46 and a fracture simulator 47. The fracture control system 46 monitors and controls the fracture treatment 10. The fracture control system 46 can control the pump trucks 40 and fluid valves to stop and start the fracture treatment 10 as well as to stop and start the pad phase, proppant phase and/or flush phase of the fracture treatment 10. The fracture control system 46 communicates with surface and/or subsurface instruments to monitor and control the fracture treatment 10. In some implementations, the surface and subsurface instruments may include surface sensors 48, down-hole sensors 50 and pump controls 52.

A quantity of energy applied by the fracture control system 46 to generate the fractures 60 in the reservoir or formation 14 can be affected not only by the properties of the reservoir rock in the formation but also by the organic matter (for example, kerogen 75) intertwined within the rock matrix.

FIG. 2 is a flowchart showing operations in process 200 for fracturing a reservoir with a geopolymer precursor fluid. The geopolymer precursor fluid is typically a solid-in-liquid dispersion including an aluminosilicate, an alkaline reagent, and a permeability enhancing agent, which can be present in a range of 0.1 vol % to 95 vol %, 0.1 vol % to 60 vol %, and 0 vol % to 95 vol %, respectively. An average particle diameter of solid components in the geopolymer precursor fluid is typically up to 0.1 μm or up to 1 cm. The geopolymer precursor fluid has a viscosity that allows it to flow inside fractures and minimize leak-off. At reservoir temperature viscosity can be in the range of 0.01 cP to 10000 cP. As such, the geopolymer precursor fluid can be used to create fractures in a reservoir.

Polymerization of the geopolymer precursor fluid yields a geopolymer. As used herein, “geopolymer” generally refers to an amorphous polymer having an Si—O—Al framework formed by polymerization of aluminosilicate. In some embodiments, a geopolymer is completely inorganic. In other embodiments, a geopolymer includes organic moieties. Components of the geopolymer precursor fluid may be selected to yield a geopolymer having a silicon (Si) to aluminum (Al) ratio (Si/Al ratio) between about 0.5:1 and about 2:1, between about 1:1 and about 2:1, between about 1:1 and about 1.5:1, or between about 0.5:1 and about 1:1.

The aluminosilicate in the geopolymer precursor fluid includes at least one of calcined clay, kaolinite, laterite, volcanic rock, mine tailings, blast furnace slag, and coal fly ash. In some embodiments, the aluminosilicate includes metakaolin, a dehydroxylated form of kaolinite. In some embodiments, the aluminosilicate includes low calcium fly ash (ASTM class F fly ash). In certain embodiments, calcium fly ash is preferred over high calcium fly ash (ASTM class C fly ash), due at least in part to interference of a large amount of calcium with the polymerization process and subsequent alteration of the microstructure of the solidified geopolymer. However, aluminosilicate with a greater amount of calcium can produce a geopolymer with higher compressive strength, due at least in part to the formation of calcium-aluminum-hydrates and other calcium compounds. In some embodiments, the aluminosilicate includes fly ash. Fly ash can be advantageously used as the aluminosilicate due at least in part to its fine particle size. The aluminosilicate may be selected based at least in part on color, particle size, and purity of the source material.

The alkaline reagent may include any alkaline reagent that reacts with aluminosilicate to yield a geopolymer. Exemplary alkaline reagents include aqueous solutions of sodium silicate, potassium silicate, calcium silicate, cesium silicate, sodium hydroxide, potassium hydroxide, and calcium hydroxide. Other suitable alkaline reagents include buffers such as hydroxides, carbonates, bicarbonates, amines, or a combination thereof.

Permeability enhancing agents include components that create conductive void spaces within proppant pillars formed by the geopolymer precursor fluid. Permeability enhancing agents include components that decompose under ambient conditions in the reservoir, water-soluble components that dissolve in water present in the reservoir, reactants that release gas or foam in the geopolymer precursor fluid, and vegetable oil. Examples of permeability enhancing agents include polylactic acid (e.g., in the form of beads, fiber, or fabric), resins, salts, benzoic acid, and wax beads. Suitable salts include sodium chloride, calcium chloride, potassium chloride, and the like.

In some embodiments, the geopolymer precursor fluid includes an accelerating agent to accelerate formation of the geopolymer in the reservoir. Examples of suitable accelerating agents include reagents that increase a pH of the fluid, such as such as hydroxides, carbonates, bicarbonates, amines, or a combination thereof.

In some embodiments, the geopolymer precursor fluid includes a retarding agent to retard formation of the geopolymer in the reservoir. Suitable retarding agents include esters that generate acids. Examples of suitable retarding agents include polylactic acid, ethyl ethanoate, ethyl propanoate, propyl methanoate, methyl butanate, and propyl ethanoate.

Referring again to FIG. 2, in 202, a pad fluid is provided to the reservoir via a wellbore to create fractures in the reservoir. Suitable pad fluids include slickwater, linear gels, crosslinked gels, and viscoelastic surfactant fluids. “Slickwater” generally refers to a low-viscosity fluid pumped at a high rate to generate narrow, complex fractures with low-concentrations of propping agent. “Linear gel” generally refers to an uncrosslinked solution of polysaccharides such as guar, derivatized-guar, HEC, or xanthan and having a viscosity of up to about 100 cP at surface temperature. “Crosslinked gel” generally refers to polysaccharides such as guar, derivatized-guar, HEC, or xanthan crosslinked with a crosslinker such as boron, zirconium, titanium, or aluminum, and having a viscosity of about 100 cP to about 1000 cP at surface temperature. “Viscoelastic surfactant fluid” generally refers to a polymer-free fluid that generates a viscosity suitable for fracturing operations without the use of polymer additives. In some embodiments, the pad fluid is a geopolymer precursor fluid.

In 204, a fracturing fluid is provided to the fractures via the wellbore. Suitable fracturing fluids include slickwater, linear gels, crosslinked gels, and viscoelastic surfactant fluids. In some embodiments, the fracturing fluid is a geopolymer precursor fluid. The fracturing fluid may include a proppant loading of up to about 12 pounds per gallon added.

The proppant may be a resin-coated proppant, an encapsulated resin, or a combination thereof. A proppant is a material that keeps an induced hydraulic fracture at least partially open during or after a fracturing treatment. Proppants can be transported into the reservoir and to the fractures using fluid, such as fracturing fluid or another fluid. A higher-viscosity fluid can more effectively transport proppants to a desired location in a fracture, especially larger proppants, by more effectively keeping proppants in a suspended state within the fluid. Examples of proppants include sand, gravel, glass beads, polymer beads, ground products from shells and seeds such as walnut hulls, and manmade materials such as ceramic proppant, bauxite, tetrafluoroethylene materials (for example, TEFLON™ available from DuPont), fruit pit materials, processed wood, composite particulates prepared from a binder and fine grade particulates such as silica, alumina, fumed silica, carbon black, graphite, mica, titanium dioxide, meta-silicate, calcium silicate, kaolin, talc, zirconia, boron, fly ash, hollow glass microspheres, and solid glass, or mixtures thereof. In some embodiments, proppant can have an average particle size, in which particle size is the largest dimension of a particle, of about 0.001 mm to about 3 mm, about 0.15 mm to about 2.5 mm, about 0.25 mm to about 0.43 mm, about 0.43 mm to about 0.85 mm, about 0.85 mm to about 1.18 mm, about 1.18 mm to about 1.70 mm, or about 1.70 to about 2.36 mm. In some embodiments, the proppant can have a distribution of particle sizes clustering around multiple averages, such as one, two, three, or four different average particle sizes. The composition or mixture can include any suitable amount of proppant, such as about 0.000.1 wt % to about 99.9 wt %, about 0.1 wt % to about 80 wt %, or about 10 wt % to about 60 wt %, or about 0.000,000,01 wt % or less, or about 0.000001 wt %, 0.0001, 0.001, 0.01, 0.1, 1, 2, 3, 4, 5, 10, 15, 20, 30, 40, 50, 60, 70, 80, 85, 90, 91, 92, 93, 94, 95, 96, 97, 98, 99, 99.9 wt %, or about 99.99 wt % or more.

In 206, a geopolymer precursor fluid is provided to the fractures via the wellbore. In some embodiments, providing the geopolymer precursor fluid to the fractures includes pulsing quantities of the geopolymer precursor fluid into a continuous flow of the fracturing fluid. The quantities of the geopolymer precursor fluid may be discrete quantities that are spaced apart from each other. Pulsing quantities of the geopolymer precursor fluid into a continuous flow of the fracturing fluid may be achieved by fracturing pumps. In some embodiments, providing the geopolymer precursor fluid to the fractures includes alternately pulsing quantities of the geopolymer precursor fluid and the fracturing fluid. The quantities of the geopolymer precursor fluid may be discrete quantities that are spaced apart from each other by the quantities of the fracturing fluid, and vice versa.

Pulsing the quantities of the geopolymer precursor fluid may include injecting the geopolymer precursor fluid at a rate between 1 barrel per minute and 120 barrels per minute, or between 5 barrels per minute and 50 barrels per minute for a pumping time between 2 seconds and 10 minutes, or between 10 seconds and 1 minute. Pulsing the quantities of the fracturing fluid may include injecting the fracturing fluid at a rate between 1 barrel per minute and 120 barrels per minute, or between 5 barrels per minute and 50 barrels per minute for a pumping time between 2 seconds and 10 minutes, or between 10 seconds and 1 minute.

In some embodiments, the fracturing fluid in 204 is a geopolymer precursor fluid that differs in composition from the geopolymer precursor fluid in 206. In certain embodiments, the fracturing fluid in 204 includes different chemical components than the geopolymer precursor fluid in 206. In certain embodiments, the fracturing fluid in 204 includes the same components as the geopolymer precursor fluid in 206 in different concentrations.

In 208, an additional fluid is optionally provided to the fractures via the wellbore. The additional fluid is typically provided continuously (not pulsed). The additional fluid is typically a fracturing fluid. The fracturing fluid can include a proppant. In one example, the proppant loading is up to about 12 pounds per gallon. In some embodiments, the additional fluid is a geopolymer precursor fluid. The geopolymer precursor fluid may differ in composition from the geopolymer precursor fluid in 206. In certain embodiments, the additional fluid in 208 includes different chemical components than the geopolymer precursor fluid in 206. In certain embodiments, the additional fluid in 208 includes the same components as the geopolymer precursor fluid in 206 in different concentrations.

In 210, the wellbore is shut in at a wellbore pressure, thereby allowing the geopolymer precursor fluid to harden and to form geopolymer proppant pillars in the fractures.

FIG. 3A depicts elapsed time between pulsed quantities of geopolymer precursor fluid in a continuous flow of fracturing fluid as a function of time. Waveform 300 represents the pulsed flow of geopolymer precursor fluid, and waveform 310 represents the continuous flow of fracturing fluid. Geopolymer injection segments 302 of waveform 300 correspond to operation of the pump that injects the geopolymer precursor fluid (“pump on”). A duration t_(g1) of geopolymer injection segments 302 is typically in a range of 2 seconds to 10 minutes, or between 10 seconds and 1 minute, and can be the same or different for one or more geopolymer injection segments. Geopolymer injection segments 302 are separated in time by geopolymer noninjection segments 304. Geopolymer noninjection segments 304 correspond to cessation of the pump that injects the geopolymer precursor fluid (“pump off”). A duration t_(g0) of geopolymer noninjection segments 304, is typically in a range of 2 seconds to 20 minutes.

FIG. 3B depicts elapsed time between pulsed quantities of geopolymer precursor fluid and fracturing fluid. Waveform 300 represents the pulsed flow of geopolymer precursor fluid, and waveform 310 represents the pulsed flow of fracturing fluid. Geopolymer injection segments 302 of waveform 300 correspond to operation of the pump that injects the geopolymer precursor fluid (“pump on”). A duration to of geopolymer injection segments 302 is typically in a range of 2 seconds to 10 minutes, or 10 seconds to 1 minute, and can be the same or different for one or more geopolymer injection segments. Geopolymer injection segments 302 are separated in time by geopolymer noninjection segments 304. Geopolymer noninjection segments 304 correspond to cessation of the pump that injects the geopolymer precursor fluid (“pump off”). A duration t_(g0) of geopolymer noninjection segments 304, is typically in a range of 2 seconds to 20 minutes. Fracturing fluid injection segments 312 of waveform 310 correspond to operation of the pump that injects the fracturing fluid (“pump on”). A duration t_(f1) of fracturing fluid injection segments 312 is typically in a range of 2 seconds to 10 minutes, or 10 seconds to 1 minute, and can be the same or different for one or more fracturing fluid injection segments. Fracturing fluid injection segments 312 are separated in time by fracturing fluid noninjection segments 314. Fracturing fluid noninjection segments 314 correspond to cessation of the pump that injects the fracturing fluid (“pump off”). A duration t_(f0) of fracturing fluid noninjection segments 314, is typically in a range of 2 seconds to 15 minutes. As depicted in FIG. 3B, geopolymer injection segments 302 correspond to fracturing fluid noninjection segments 314, and geopolymer noninjection segments 304 correspond to fracturing fluid injection segments 312.

In some embodiments, geopolymer injection segments 302 and fracturing fluid injection segments 312 may be separated in time by a duration t_(fg). FIG. 3C depicts elapsed time between pulsed quantities of geopolymer precursor fluid and fracturing fluid. Waveform 300 represents the pulsed flow of geopolymer precursor fluid, and waveform 310 represents the pulsed flow of fracturing fluid. Elapsed time between geopolymer injection segments 302 and fracturing fluid injection segments 312, t_(fg), may be the same or different, and is typically in a range of 2 seconds to 15 minutes.

In some embodiments, geopolymer injection segments 302 and fracturing fluid injection segments 312 may overlap in time by a duration t_(fg). FIG. 3D depicts elapsed time between pulsed quantities of geopolymer precursor fluid and fracturing fluid. Waveform 300 represents the pulsed flow of geopolymer precursor fluid, and waveform 310 represents the pulsed flow of geopolymer precursor fluid. A duration of the overlap between geopolymer injection segments 302 and fracturing fluid injection segments 312, t_(fg), may be the same or different, and is typically in a range of 2 seconds to 20 minutes.

In certain embodiments, geopolymer injection segments and fracturing fluid injection segments may be separated in time, overlap in time, or any combination thereof.

FIG. 4 depicts a fracture 400 with geopolymer proppant pillars 402 and conductive channels 404 between the pillars. In some embodiments, an accelerating agent is included in the geopolymer precursor fluid to reduce the length of time required to polymerize the geopolymer precursor fluid to yield a geopolymer. In some embodiments, a retarding agent is included in the geopolymer precursor fluid to increase the length of time required to polymerize the geopolymer precursor fluid to yield a geopolymer. Suitable curing and shut-in times range from less than an hour (e.g., half an hour) to days (e.g., 20 days).

A compressive strength of the geopolymer proppant pillars may exceed the overburden pressure of the reservoir. In some embodiments, a compressive strength of the geopolymer proppant pillars is in a range of about 500 psi to about 20,000 psi. In some embodiments, a permeability of the geopolymer pillars is about 0.01 mD to about 20,000 D.

It is to be understood that while the invention has been described in conjunction with the detailed description thereof, the foregoing description is intended to illustrate and not limit the scope of the invention, which is defined by the scope of the appended claims. Other aspects, advantages, and modifications are within the scope of the following claims. 

What is claimed is:
 1. A method of fracturing a reservoir, comprising: injecting a fracturing fluid into the reservoir via a wellbore to create fractures in the reservoir; pulsing quantities of a geopolymer precursor fluid into a continuous flow of the fracturing fluid or alternately pulsing quantities of the geopolymer precursor fluid and the fracturing fluid, wherein an elapsed time between pulsing the quantities of the geopolymer precursor fluid is between 2 seconds and 20 minutes; and shutting in the wellbore at a wellbore pressure, thereby allowing the geopolymer precursor fluid to polymerize and harden in the fractures and form geopolymer proppant pillars.
 2. The method of claim 1, wherein injecting the fracturing fluid comprises pumping the fracturing fluid to apply energy to create the fractures with the fracturing fluid, wherein the fracturing fluid comprises slickwater, a linear gel, a crosslinked gel, or a viscoelastic surfactant fluid, and wherein the fracturing fluid does not comprise proppant.
 3. The method of claim 1, wherein the geopolymer precursor fluid comprises aluminosilicate, an alkaline reagent, and a permeability enhancing agent, and wherein the geopolymer precursor fluid does not comprise proppant.
 4. The method of claim 3, wherein the aluminosilicate comprises at least one of calcined clay, kaolinitic clay, lateritic clay, volcanic rock, mine tailings, blast furnace slag, or coal fly ash, wherein the alkaline reagent comprises at least one of sodium silicate or potassium silicate, and wherein the fracturing fluid is slickwater or a viscoelastic surfactant fluid.
 5. The method of claim 3, wherein the permeability enhancing agent comprises polylactic acid as beads, fibers, or fabric, or any combinations thereof.
 6. The method of claim 3, wherein the permeability enhancing agent comprises at least one of an acid salt, benzoic acid, or wax beads.
 7. The method of claim 1, wherein the geopolymer precursor fluid comprises an accelerating agent or a retarding agent.
 8. The method of claim 1, wherein the elapsed time between pulsing the quantities of the geopolymer precursor fluid is between 10 seconds and 1 minute, and wherein the fracturing fluid does not comprise a linear gel or a crosslinked gel.
 9. The method of claim 1, wherein pulsing the quantities of the geopolymer precursor fluid comprises injecting the geopolymer precursor fluid at a rate between 1 barrel per minute and 120 barrels per minute, and wherein proppant is not transported to the fractures.
 10. The method of claim 1, wherein pulsing the quantities of the geopolymer precursor fluid comprises injecting the geopolymer precursor fluid at a rate between 5 barrels per minute and 50 barrels per minute.
 11. The method of claim 1, wherein a compressive strength of the geopolymer proppant pillars exceeds an overburden pressure of the reservoir, wherein the compressive strength of the geopolymer proppant pillars is in a range of 500 pounds per square inch to 20,000 pounds per square inch, and wherein a permeability of the geopolymer proppant pillars is in a range of 0.00001 Darcy to 20,000 Darcy.
 12. The method of claim 1, wherein the fracturing fluid does not comprise geopolymer precursor fluid.
 13. A method of fracturing a reservoir, comprising: injecting a fracturing fluid into the reservoir via a wellbore to create fractures in the reservoir; pulsing a geopolymer precursor fluid into a continuous flow of the fracturing fluid or alternately pulsing the geopolymer precursor fluid and the fracturing fluid, wherein an elapsed time between pulsing the geopolymer precursor fluid is between 2 seconds and 20 minutes, wherein the geopolymer precursor fluid comprises aluminosilicate, an alkaline reagent, and a permeability enhancing agent, and wherein the geopolymer precursor fluid does not comprise proppant; and shutting in the wellbore at a wellbore pressure, thereby allowing the geopolymer precursor fluid to polymerize to form geopolymer pillars in the fractures, wherein a compressive strength of the geopolymer pillars exceeds an overburden pressure of the reservoir.
 14. The method of claim 13, wherein the fracturing fluid does not comprise proppant, and wherein the compressive strength of the geopolymer pillars is in a range of 500 pounds per square inch to 20,000 pounds per square inch.
 15. The method of claim 13, wherein the fracturing fluid comprises slickwater or a viscoelastic surfactant fluid.
 16. The method of claim 13, wherein the permeability enhancing agent comprises at least one of polylactic acid, an acid salt, benzoic acid, or wax beads, and wherein a permeability of the geopolymer pillars is in a range of 0.00001 Darcy to 20,000 Darcy.
 17. A method of fracturing a reservoir, comprising: injecting a fracturing fluid via a wellbore into the reservoir to create fractures in the reservoir, wherein the fracturing fluid does not comprise proppant; injecting a geopolymer precursor fluid via the wellbore into the fractures in an isolated pattern shape in the fractures to form isolated geopolymer proppant pillars giving conductive channels for hydrocarbon flow, wherein injecting the geopolymer precursor fluid comprises pulsing the geopolymer precursor fluid into a continuous flow of the fracturing fluid or alternately pulsing the geopolymer precursor fluid and the fracturing fluid, and wherein the geopolymer precursor fluid does not comprise proppant; and allowing the geopolymer precursor fluid to polymerize to yield a geopolymer to form the geopolymer proppant pillars in the fractures, wherein the geopolymer proppant pillars do not comprise proppant transported to the fractures.
 18. The method of claim 17, wherein an elapsed time between pulsing the geopolymer precursor fluid is between 2 seconds and 20 minutes, wherein the geopolymer precursor fluid comprises aluminosilicate, an alkaline reagent, and a permeability enhancing agent, and wherein the permeability enhancing agent comprises at least one of polylactic acid, an acid salt, benzoic acid, or wax beads.
 19. The method of claim 18, wherein the aluminosilicate comprises at least one of calcined clay, kaolinitic clay, lateritic clay, volcanic rock, mine tailings, blast furnace slag, or coal fly ash, wherein the alkaline reagent comprises at least one of sodium silicate or potassium silicate, and wherein compressive strength of the geopolymer proppant pillars is in a range of 500 pounds per square inch to 20,000 pounds per square inch.
 20. The method of claim 17, wherein the fracturing fluid does not comprise a linear gel or a crosslinked gel, and wherein injecting the geopolymer precursor fluid during the pulsing of the geopolymer precursor fluid comprises injecting the geopolymer precursor fluid at a rate in a range of 1 barrel per minute to 120 barrels per minute. 